Use of cuttings tanks for recycling oil based mud and water

ABSTRACT

A system for recycling a drilling fluid that includes a first cuttings storage vessel, a second cuttings storage vessel, and a module fluidly connected to the first and second cuttings storage vessels, the module having a valve configured to fluidly connect the first and second cuttings storage vessels. The module further includes a filter system configured to fluidly connect to at least the second cuttings storage vessel, and at least one pump to facilitate the flow of a fluid between the first and second cuttings storage vessels.

CROSS-REFERENCE TO RELATED APPLICATION

This present application is a continuation application, and thus claimsbenefit pursuant to 35 U.S.C. §120 of U.S. patent application Ser. No.12/020,067 filed Jan. 25, 2008, currently pending, which claims priorityunder 35 U.S.C. §119(e) to U.S. Provisional Application Ser. No.60/887,444, filed Jan. 31, 2007. That application is incorporated byreference in its entirety.

BACKGROUND

1. Field of the Disclosure

Embodiments disclosed herein relate generally to systems and methods forrecycling drilling fluids at a drilling location. More specifically,embodiments disclosed herein relate to systems and methods for recyclingdrilling fluids at a drilling location using a module-based drillingfluid recovery system. More specifically still, embodiments disclosedherein relate to systems and methods for recycling drilling fluids at adrilling location using a module to convert cutting storage and transfervessels into a drilling fluid recovery system.

2. Background

In the drilling of wells, a drill bit is used to dig many thousands offeet into the earth's crust. Oil rigs typically employ a derrick thatextends above the well drilling platform. The derrick supports jointafter joint of drill pipe connected end to end during the drillingoperation. As the drill bit is pushed further into the earth, additionalpipe joints are added to the ever lengthening “string” or “drillstring”. Therefore, the drill string includes a plurality of joints ofpipe.

Fluid “drilling mud” is pumped from the well drilling platform, throughthe drill string, and to a drill bit supported at the lower or distalend of the drill string. The drilling mud lubricates the drill bit andcarries away well cuttings generated by the drill bit as it digs deeper.The cuttings are carried in a return flow stream of drilling mud throughthe well annulus and back to the well drilling platform at the earth'ssurface. When the drilling mud reaches the platform, it is contaminatedwith small pieces of shale and rock that are known in the industry aswell cuttings or drill cuttings. Once the drill cuttings, drilling mud,and other waste reach the platform, a “shale shaker” is typically usedto remove the drilling mud from the drill cuttings so that the drillingmud may be reused. The remaining drill cuttings, waste, and residualdrilling mud are then transferred to a holding trough for disposal. Insome situations, for example with specific types of drilling mud, thedrilling mud may not be reused and it must be disposed. Typically, thenon-recycled drilling mud is disposed of separate from the drillcuttings and other waste by transporting the drilling mud via a vesselto a disposal site.

The disposal of the drill cuttings and drilling mud is a complexenvironmental problem. Drill cuttings contain not only the residualdrilling mud product that would contaminate the surrounding environment,but may also contain oil and other waste that is particularly hazardousto the environment, especially when drilling in a marine environment.

In the Gulf of Mexico, for example, there are hundreds of drillingplatforms that drill for oil and gas by drilling into the subsea floor.These drilling platforms may be used in places where the depth of thewater is many hundreds of feet. In such a marine environment, the wateris typically filled with marine life that cannot tolerate the disposalof drill cuttings waste. Therefore, there is a need for a simple, yetworkable solution to the problem of disposing of well cuttings, drillingmud, and/or other waste in marine and other fragile environments.

Traditional methods of disposal include dumping, bucket transport,cumbersome conveyor belts, screw conveyors, and washing techniques thatrequire large amounts of water. Adding water creates additional problemsof added volume and bulk, pollution, and transport problems. Installingconveyors requires major modification to the rig area and involvesextensive installation hours and very high cost.

Another method of disposal includes returning the drill cuttings,drilling mud, and/or other waste via injection under high pressure intoan earth formation. Generally, the injection process involves thepreparation of a slurry within surface-based equipment and pumping theslurry into a well that extends relatively deep underground into areceiving stratum or adequate formation. The basic steps in the processinclude the identification of an appropriate stratum or formation forthe injection; preparing an appropriate injection well; formulation ofthe slurry, which includes considering such factors as weight, solidscontent, pH, gels, etc.; performing the injection operations, whichincludes determining and monitoring pump rates such as volume per unittime and pressure; and capping the well.

In some instances, the cuttings, which are still contaminated with someoil, are transported from a drilling rig to an offshore rig or ashore inthe form of a thick heavy paste or slurry for injection into an earthformation. Typically the material is put into special skips of about 10ton capacity that are loaded by crane from the rig onto supply boats.This is a difficult and dangerous operation that may be laborious andexpensive.

U.S. Pat. No. 6,709,216 and related patent family members disclose thatcuttings may also be conveyed to and stored in an enclosed,transportable vessel, where the vessel may then be transported to adestination, and the drill cuttings may be withdrawn. The transportablestorage vessel has a lower conical section structured to achieve massflow of the mixture in the vessel, and withdrawal of the cuttingsincludes applying a compressed gas to the cuttings in the vessel. Thetransportable vessels are designed to fit within a 20 foot ISO containerframe. These conical vessels will be referred to herein as ISO vessels.

As described in U.S. Pat. No. 6,709,216 and family, the ISO vessels maybe lifted onto a drilling rig by a rig crane and used to store cuttings.The vessels may then be used to transfer the cuttings onto a supplyboat, and may also serve as buffer storage while a supply boat is notpresent. Alternatively, the storage vessels may be lifted off the rig bycranes and transported by a supply boat.

Space on offshore platforms is limited. In addition to the storage andtransfer of cuttings, many additional operations take place on adrilling rig, including tank cleaning, slurrification operations,drilling, chemical treatment operations, raw material storage, mudpreparation, mud recycle, mud separations, and others.

Due to the limited space, it is common to modularize these operationsand to swap out modules when not needed or when space is needed for theequipment. For example, cuttings containers may be offloaded from therig to make room for modularized equipment used for slurrification.These lifting operations, as mentioned above, are difficult, dangerous,and expensive. Additionally, many of these modularized operationsinclude redundant equipment, such as pumps, valves, and tanks or storagevessels.

In other drilling operations, cuttings containers may be offloaded fromthe rig to make room for environmental and/or drilling fluid recyclingsystems. Such systems may include a number of mixing, flocculating, andstorage tanks to clean industrial wastewater produced during drilling orshipping operations. Examples of such environmental and drilling fluidrecycling methods and systems are disclosed in U.S. Pat. Nos. 6,881,349and 6,977,048, assigned to the assignee of the present application, andhereby incorporated in their entirety. While theses systems and methodsprovide improved processes in recycling drilling fluid, they require thedifficult, dangerous, and expensive lifting and installation operations,as described above.

Accordingly, there exists a continuing need for systems and methods forefficiently recycling drilling fluids at a drilling location.

SUMMARY OF THE DISCLOSURE

In one aspect, embodiments disclosed herein relate to a system forrecycling a drilling fluid that includes a first cuttings storage vesseland a second cuttings storage vessel. The system further includes amodule fluidly connected to the first and second cuttings storagevessels, the module having a valve configured to fluidly connect thefirst and second cuttings storage vessels. The module further includes afilter system configured to fluidly connect to at least the secondcuttings storage vessel, and at least one pump to facilitate the flow ofa fluid between the first and second cuttings storage vessels.

In another aspect, embodiments disclosed herein relate to a module foruse at a drilling location that includes a valve for directing drillingfluid between at least a first cuttings storage vessel disposed outsidethe module and a second cuttings storage vessel disposed outside themodule. The module further includes a filter system for filtering thedrilling fluid and at least one pump for facilitating the flow of thefluid between at least the first and second cuttings storage vessels.

In another aspect, embodiments disclosed herein relate to a method ofoperating a drilling fluid recycling system including using a vessel forcuttings storage, and operating the vessel in a drill fluid recyclingsystem.

Other aspects and advantages of the disclosure will be apparent from thefollowing description and the appended claims.

BRIEF DESCRIPTION OF DRAWINGS

FIG. 1 shows a method of offloading drill cuttings from an off-shore rigaccording to one embodiment of the present disclosure.

FIG. 2 shows a top view of a system for recycling drilling fluidaccording to one embodiment of the present disclosure.

FIGS. 3-6 show systems for recycling drilling fluid according toembodiments of the present disclosure.

DETAILED DESCRIPTION

In one aspect, embodiments disclosed herein relate to systems andmethods for recycling drilling fluids at a drilling location. Thedrilling location may include both onshore and offshore drill sites.Additionally, embodiments disclosed herein relate to systems and methodsfor recycling drilling fluids using a module-based drilling fluidrecovery system. More specifically, such embodiments relate to methodsof using a module-based drilling fluid recovery system to convertcuttings storage and transfer vessels into components of the drillingfluid recovery system.

Referring initially to FIG. 1, a method of offloading drill cuttingsfrom an offshore drilling rig according to one embodiment of the presentdisclosure is shown. In this embodiment, an offshore rig 1 may have oneor more cuttings storage vessels 2 located on its platform. Cuttingsstorage vessels 2 may include raw material storage tanks, waste storagetanks, or any other vessels commonly used in association with drillingprocesses. Specifically, cuttings storage vessels 2 may include, forexample, cuttings boxes and/or ISO-tanks (i.e., InternationalOrganization for Standardization tanks). In some embodiments, cuttingsstorage vessels 2 may include several individual vessels fluidlyconnected to allow the transference of cuttings therebetween. Suchcuttings storage vessels 2 may be located within a support framework(not shown), such as an ISO container frame. As such, those of ordinaryskill in the art will appreciate that cuttings storage vessels 2 may beused for both drill cuttings storage and transport.

As described above with respect to prior art methods, when cuttingsstorage vessels 2 are no longer needed during a drilling operation, orare temporarily not required for operations taking place at the drillinglocation, cuttings storage vessels 2 may be offloaded to a supply boat3. Other systems and vessels for performing different operations maythen be lifted onto the rig via crane 11, and placed where cuttingsstorage vessels 2 were previously located. In this manner, valuable rigspace may be saved; however, conserving space in this manner may requiremultiple dangerous and costly crane lifts.

In contrast to the prior art methods described above, embodimentsdisclosed herein integrate cuttings storage vessels 2 into two or moreoperations that are performed on drilling rig 1. In one aspect,embodiments disclosed herein relate to integrating cuttings storagevessel 2 to operate in at least two operations on rig 1. In someaspects, embodiments disclosed herein relate to integrating cuttingsstorage vessel 2 to be used for both cuttings storage/transfer, as wellas a second operation. More specifically, embodiments disclosed hereinrelate to using cuttings storage vessel 2 as both a storage/transfervessel, as well as a component in a drilling fluid recovery system.Although described with respect to integrating cuttings storage vessel 2into a drilling fluid recovery system, those skilled in the art willappreciate that any vessel located at a drill site for performing aspecified drilling operation may be integrated into the systems andmethods for recycling drilling fluid disclosed herein. Furthermore,those of ordinary skill in the art will appreciate that the system forrecycling drilling fluid may include a number of environmental methodsfor treating and/or cleaning drilling fluid and drilling waste products,as are described below.

Still referring to FIG. 1, offshore rig 1 may include one or morecuttings storage vessels 2 located on its platform. Drill cuttingsgenerated during the drilling process may be transferred to cuttingstorage vessels 2 for storage and/or subsequent transfer in a number ofdifferent ways. One such method of transferring drill cuttings is via apneumatic transfer system including a cuttings blower 4 and pneumatictransfer lines 5. Examples of systems using forced flow pneumatictransfer are disclosed in U.S. Pat. Nos. 6,698,989, 6,702,539, and6,709216, hereby incorporated by reference herein. However, those ofordinary skill in the art will appreciate that other methods fortransferring cuttings from a cleaning operation (e.g., using vibratoryseparators) to cuttings storage vessels 2 may include augers, conveyors,and pneumatic suction systems.

In a system using pneumatic cuttings transfer, when cuttings need to beoffloaded from a rig 1 to supply boat 3, cuttings may be dischargedthrough pipe 6 to a hose connection pipe 7. Supply boat 3 is fitted witha supply assembly 8, wherein supply assembly 8 may include a number ofadditional cuttings storage vessels 9, including, for example,ISO-tanks. Supply boat 3 may be brought proximate to rig 1, and aflexible hose 10 extended therebetween. In this embodiment, flexiblehose 10 fluidly connects storage assembly 8 to cuttings storage vessels2 via connection pipe 7.

Referring to FIG. 2, a rig 201 including a drilling fluid recyclingmodule 212 in accordance with one embodiment of the present disclosureis shown. In this embodiment, rig 201 includes a set of cuttings storagevessels 202 fluidly connected to recycling module 212 via a connectionline 213. Cutting storage vessels 202 are detachably connected to asecond set of storage vessels 209 located on a supply boat 203 by aflexible hose 210.

In operation, dry cuttings may be transferred to cuttings storagevessels 202 from a pneumatic transfer device 214 located on rig 201.Pneumatic transfer device 214 may include, for example, a mass flowpneumatic transfer system, a vacuum assist transfer system, a cuttingsblower, or an ISO-Pump™, as described above. The dry cuttings may bestored in cuttings storage vessels 202 until they are transferred tosupply boat 203 for transport or disposal thereafter. Typically, duringcleaning of the drill cuttings, upstream cleaning devices (e.g.,vibratory shakers) generate both dry cuttings and fluids. While thecuttings may be transferred to cuttings storage vessels 202, the fluidsare collected in a drilling fluid reservoir 215. Examples of reservoirsmay include storage tanks, pits, and collection vats, and those ofordinary skill in the art will appreciate that such reservoirs alreadyexist as part of the rig 201 infrastructure.

In one embodiment, fluid reservoir 215 is fluidly connected to fluidrecycling module 212 and/or cuttings storage vessels 202 via transferlines 216. Transfer lines 216 may include flexible hosing and/orpreexisting fluid communication lines used to transfer drilling fluidbetween operations on rig 201. As described above, drilling fluids aretypically cleaned and recycled in independent systems located on rig 201either permanently, or transferred to rig 201 from supply boat 203, whensuch operations are required. However, in this embodiment, fluidrecycling module 212 is located on rig 201 proximate cuttings storagevessels 202, and transfer lines 213 and 216 are connected therebetweento integrate the cuttings storage vessels 202 and module 212 withpreexisting fluid reservoirs 215. Such an integrated system allows forexisting single-use structures (e.g., cuttings storage vessels 202) tobe used in multiple operations (e.g., fluid recycling systems). Thus, inthis embodiment, used drilling fluid collected either from the wellboreor from upstream cleaning operations may be pumped from drillingreservoir 215 to cuttings storage vessels 202 for cleaning and/orrecycling.

As described above, previous fluid cleaning and recycling methodsrequired the conversion of valuable drilling rig space for storingindependent fluid recovery vessels and processing equipment. However,embodiments disclosed herein allow existing structural elements (i.e.,cuttings storage vessels 202 and fluid reservoirs 215) to be used inmultiple operations. Fluid recycling module 212 is relatively smallcompared to previous systems, thereby preserving valuable drill space,and preventing the need for costly and dangerous lifting operations.Those of ordinary skill in the art will appreciate that the system, asillustrated in FIGS. 1 and 2, is only exemplary, and alternate systemsincorporating additional fluid cleaning components may also be use indrilling fluid recycling systems disclosed herein. Illustrative examplesof such systems are described in greater detail below.

Referring to FIG. 3, a system 300 for recycling drilling fluid accordingto one embodiment of the present disclosure is shown. In thisembodiment, system 300 includes a first cuttings storage vessel 301, asecond cuttings storage vessel 302, and a module 303. Module 303includes a pump 304, a valve 305, and a filter system 306. Valve 305provides fluid communication between first cuttings storage vessel 301and second cuttings storage vessel 302 and/or a drilling waste reservoir307. Drilling waste reservoir 307 may be an existing structural elementof a drilling rig, such as a mud pit or collection tank, or in alternateembodiments, may be a component of module 303. Drilling waste reservoir307 may further include a recyclable mud reservoir (not illustrated),which is often referred to as a slop tank on a rig. Second cuttingsstorage vessel 302 is fluidly connected to filter system 306, and filtersystem 306 is fluidly connected to a cleaned fluids reservoir 308.Cleaned fluids reservoir 308 may be an existing structural element of adrilling rig, or in alternate embodiments, may be a component of module303. In certain embodiments, those of ordinary skill in the art willappreciate that either drilling waste reservoir 307 or cleaned fluidsreservoir 308 may also include cuttings storage vessels 302.

During operation, used or contaminated drilling fluid, including drillcuttings, particulate matter, suspended materials, chemicals used duringthe drilling operation, and other materials commonly associated withused drilling fluid is pumped into first cuttings storage vessel 301 viasupply line 309. Other types of fluids that may be treated includefluids from various cleaning operations, such as deck and pit cleaning,fluids stored in a slop tank, and fluids from tank cleaning systems usedin the separation and cleaning of reusable drilling fluids. The useddrilling fluid may be mixed with water in first cuttings storage vessel301, or pumped into first cuttings vessel 301 without the addition ofwater and/or other additives. The mixture in first storage vessel 301may be agitated by mechanical means (e.g., an agitator) or otherwiseagitated via the addition of liquids (e.g., additional water) to themixture. After solid particles have settled to the bottom of firstcuttings storage vessel 301, the solid particles of the mixture arepumped out of first cuttings storage vessel 301 by pump 304 throughoutlet line 310. The extracted mixture may contain both a liquidcomponent and a solid component. Those of ordinary skill in the art willappreciate that due to the separation of solid particles from the useddrilling fluid in first cuttings storage vessel 301, the mixture mayinitially include a higher concentration of solids component than liquidcomponent. The mixture is pumped through valve 305, which, asillustrated, allows for the direction of the pumped mixture to beselected between second cuttings storage vessel 302 and drilling wastereservoir 307.

Initially, the pumped mixture may contain a greater percentage of solidscontent due to the separation, as describe above. A desirable percentageof solid to liquid content may vary according to specific drillingoperation requirements; however, those of ordinary skill the art willappreciate that in at least one embodiment, a desirable initial solidcontent of the pumped mixture may be greater than 50% by volume. Assuch, the pumped mixture including a desirable solid to liquid ratio fortransfer to drilling waste reservoir 307 will be hereinafter referred toas a positive mixture. In contrast, a pumped mixture including anundesirable solid to liquid ratio for transfer to drilling wastereservoir 307 will be referred to as a negative mixture. Those ofordinary skill in the art will appreciate that in certain embodiments,to recycle drilling fluids efficiently, an acceptable positive conditionmay be 30% by volume solids, 50% by volume solids, 75% by volume solids,or any volume of solids as determined by a drilling operator. Likewise,acceptable negative conditions, wherein the mixture is pumped to secondcuttings storage vessel 302, may be appropriate when the mixture is 70%by volume liquid, 50% by volume liquid, 30% by volume liquid, or anyvolume as determined by a drilling operator to achieve a desired levelof recycling efficiency.

As the pumped mixture is transferred through outlet line 310, valve 305is actuated to provide fluid communication between first cuttingsstorage vessel 301 and drilling waste reservoir 307. The positivemixture may continue to be pumped to drilling waste reservoir 307 untila negative mixture condition exists. Such a condition may occur whensubstantially all of the separated solids content from the mixture infirst cuttings storage vessel 301 is extracted.

To determine when such a condition exists, in one embodiment of thepresent disclosure, outlet line 310 may be sufficiently translucent toallow a drilling operator to visually inspect and thereby determine anapproximate solid to liquid ratio of the pumped mixture. Such visualinspection may rely on properties of the mixture such as color,viscosity, and flow rate. Upon determination of a negative condition,the drilling operator may either manually, or using automated assistmeans, actuate valve 305 to change the direction of flow of the pumpedmixture between first cuttings storage vessel 301 and drilling wastereservoir 307 to second cuttings storage vessel 302.

Valve 305 may be fluidly connected to second cuttings storage vessel 302via any of the connection means discussed above, including, for example,flexible hoses and/or existing piping. As valve 305 is actuated to allowmixture from first cutting storage vessel 301 to transfer to secondcuttings storage vessel 302, additional fluids, including water and/orchemical may be added to the mixture. Addition of such fluids may occureither during transfer of the mixture through line 312 (i.e., inline),or after the mixture reaches second cuttings storage vessel 302. Inanother embodiment, additional fluids may already exist in secondcuttings storage vessel 302 when the mixture is pumped thereto.

The mixture in second cuttings storage vessel 302 may be allowed tosettle and/or separate further, or otherwise may be agitated usingmechanical agitators (i.e., stirrers) or an inflow of fluids, asdescribed above. Those of ordinary skill in the art will appreciate thatthe level of agitation, if agitation is used, will vary based on thespecific properties of the mixture at the time such mixture istransferred to second storage vessel 302. In at least one embodiment,such as in an embodiment using existing ISO-pumps, those of ordinaryskill in the art will appreciate that no mechanical agitation means isused.

After sufficient separation of the mixture in second cuttings storagevessel 302, the solution is transferred to filter system 306. Filtersystem 306 may include a number of different filters including, forexample, hydrocarbon filters and filter presses, depending on thespecific properties of the drilling fluid being processed. Those ofordinary skill in the art will appreciate that fluids containingsubstantially low levels of hydrocarbon content may merely be filteredthrough a hydrocarbon filter, while dense fluids including large amountsof solid matter may be filtered through a filter press, centrifuge, orother filter means. Upon completion of filtration, the cleaned fluid istransferred to cleaned fluid reservoir 308. In certain embodiments,uncleaned fluid, including solids particulate matter or fluid containinghigh hydrocarbon levels may either be trapped in filter system 306,transferred to drilling waste reservoir (not shown), or recycled toeither first cuttings storage vessel 301 or second cuttings storagevessel 302 for further processing. Thus, in at least one embodiment, acleaning loop may exist allowing for the substantially continuousprocessing of drilling fluids. In such a loop, cleaned fluids may becollected in a cleaned fluids reservoir 308 for reuse in the drillingoperation, while waste products may be separated and collected in thedrilling waste reservoir 307 for disposal or further remediation.

Referring to FIG. 4, a system 400 for recycling drilling fluid in accordwith one embodiment of the present disclosure is shown. In thisembodiment, system 400 includes a first cuttings storage vessel 401, asecond cuttings storage vessel 402, and a module 403. Module 403includes a pump 404, a valve 405, a dosing tank 413, a filter system406, and a plurality of control valves 414. Valve 405 provides for thecontrol of fluid communication between first cuttings storage vessel 401and second cuttings vessel 402 and/or drilling waste reservoir 407. Asdescribed above, all structural elements including drilling wastereservoir 407 and supply lines may be existing structures at a drillinglocation.

In this embodiment, drilling fluid is pumped or otherwise communicatedfrom an upstream cleaning process into first cuttings storage vessel 401via a supply line 409. In first cuttings storage vessel 401, drillingfluid is mixed with additional water, as described above, or chemicaladditives to facilitate the precipitation and/or settling of solidsparticulates and material suspended within the drilling fluid. Theadditives and/or water may be added from dosing tank 413, wherein suchadditives are mixed, stored, and/or added to first cuttings storage tank401 via, for example, an inline pump (not shown). As illustrated, thecommunication of additives from dosing tank 413 to first cuttingsstorage tank 401 is controlled by a control valve 414, which may be, forexample, a manual valve or an automated valve, and may be controlledthrough manual actuation or according to batch sequencing, as will bediscussed in detail below.

The water and/or chemical additives added to the drilling fluid in firstcuttings storage vessel 401 may thereby promote the settling of solidmaterial from the drilling fluid. When a desirable quantity of solidmatter has separated to require a recycling operation, the settledpositive mixture is pumped via pump 404 through outlet line 410 toprimary valve 405. As described above, primary valve 405 controls theflow of the mixture between second cuttings storage vessel 402 anddrilling waste reservoir 407. In certain embodiments, drilling wastereservoir 407 may be substituted with a direct feed back to an upstreamcleaning operation (e.g., to vibratory shakers) for additional cleaning.

When the mixture reaches a negative condition, primary valve 405 directsthe flow of the mixture to second cuttings storage vessel 402 via line412. The mixture inside second cuttings storage vessel 402 may beallowed to settle and/or separate further. Such separation may befacilitated by addition of chemicals, water, or agitation, as describedabove. After such separation occurs, the mixture is pumped and/orallowed to drain into filter system 406. Filter system 406 may includeany of the types of filters described above, such as hydrocarbon filtersand filter presses, for further removing hydrocarbons and/or solidparticulate matter from the mixture. Upon completion of the filtrationprocess, the cleaned fluid is directed to cleaned fluid reservoir 408,and the remaining impurities (e.g., hydrocarbons and solid matter) maybe trapped in filter system 406, directed to drilling waste reservoir407, or otherwise collected for eventual disposal and/or furtherremediation. In this embodiment, cleaned fluid reservoir 408 includes anoutlet line 415, which may be used to transfer the cleaned fluids toother operations on the rig. Such operations may include directing thecleaned fluids for use in drilling fluid mixing vessels, fluids used inthe slurrification of cuttings for reinjection, fluids used for cleaningoperations, or for other operations which require cleaned fluids at adrilling location.

Referring now to FIG. 5, a system 500 for recycling drilling fluid inaccord with one embodiment of the present disclosure is shown. In thisembodiment, system 500 includes a first cuttings storage vessel 501, asecond cuttings storage vessel 502, and a module 503. Module 503includes a pump 504, a valve 505, dosing tanks 513 a and 513 b, and afilter system 506. Valve 505 provides for the control of fluidcommunication between first cuttings storage vessel 501 and secondcuttings vessel 502 and/or drilling waste reservoir 507. As describedabove, all structural elements including drilling waste reservoir 507and supply lines may be existing structures at a drilling location.

In this embodiment, a drilling fluid enters first cuttings storagevessel 501 through a supply line 509. The drilling fluid is allowed toseparate in first cuttings storage vessel 501 such that solid particlestend to settle toward the bottom of the vessel, while the less denseliquid phase of the drilling fluid separates toward the top of thevessel. This process may be facilitated by injecting chemical additivessuch as, for example, emulsion clearance agents from dosing tank 513 ainto first cuttings storage vessel 501. Examples of emulsion clearanceagents that may be used in embodiments disclosed herein include, forexample, anionic surfactants, nonionic surfactants, alkylpolyglycosides, and combinations thereof Other chemical additives may beinjected into first cuttings storage vessel 501 including, for example,various surfactants and wettings agents, such as, fatty acids, soaps offatty acids, amido amines, polyamides, polyamines, oleate esters,imidazoline derivatives, oxidized crude tall oil, organic phosphateesters, alkyl aromatic sulfates, sulfonates, and combinations thereofDosing of such chemical additives may vary according to the requirementsof a given fluid recycling operation; however, those of ordinary skillin the art will appreciate that in certain embodiments, minimal amountsof such additives may be used to achieve the desired result.

While drilling fluid separates in cuttings storage vessel 501, themixture may be agitated, as described above, or in certain embodimentsusing pressurized cuttings storage vessels, air may be injected into themixture. The injected air may be controlled by a pneumatic controldevice (not shown) disposed on module 503. In such an embodiment, an airline (not shown) from an air compressor (not shown) may be coupled tothe pneumatic control device (not shown) on module 503 to control a flowof air into first cuttings storage vessel 501. Those of ordinary skillin the art will appreciate that air is only one additional example of amethod to agitate the mixture in cuttings storage vessel 501. Othermethods may include stirring devices, water injection, chemicalinjection, heat, steam injection, or any other method of agitating asolution known in the art.

Still referring to FIG. 5, in this embodiment, when the mixture incuttings storage vessel 501 is separated to a desirable level, the solidcuttings waste that has collected toward the bottom of cuttings storagevessel 501 is pumped out of the vessel via pump 518 through line 516.The mixture is then pumped through valve 505, and if the mixture is in apositive condition, pumped directly to filter system 506. In thisembodiment, filter system 506 is a compound filter module including afilter press 506 a and a hydrocarbon filter 506 b. The dense, generallysolids component, may be further separated from any residual liquidphase, such that filter press 506 a directs the solids to drilling wastereservoir 507, while directing any liquid phase back to cuttings storagevessel 501 via a return line 517. In certain embodiments, return line517 may be incorporated into module 503, and the return of any suchliquid phase from filter press 506 a to cuttings storage vessel 501 maybe facilitated with a pump (not shown).

When the mixture in first cuttings storage vessel 501 reaches a negativecondition, valve 505 may be used to direct the mixture to cuttingsstorage vessel 502 via line 512. In this embodiment, a substantiallyliquid portion of the mixture in first cuttings storage vessel 501, in anegative condition, may be pumped to second cuttings storage vessel 502for further processing by actuation of pump 504, while valve 505 directsthe mixture through line 512. As described above, should the conditionof the mixture change (i.e., become positive), the mixture may bedirected to filter press 506 a. In still other embodiments, those ofordinary skill in the art will appreciate that multiple valves similarto valve 505 (e.g., R-valves), may be used to direct simultaneous flowsof the mixture in first cuttings storage vessel 501 to differentcomponents of system 500, such as, for example, filter press 506 a,drilling waste reservoir 507, or cuttings storage vessel 502, atsubstantially the same time. Thus, in at least one embodiment, a valvesystem (not independently illustrated) may be foreseen that promotes thesimultaneous processing of both positive and negative mixtures in firstcuttings storage vessel 501.

As the mixture is pumped via line 524 into second cuttings storagevessel 502, additional chemicals may be added to the mixture via adosing tank 513 b. Examples of chemicals that may be added includeanionic surfactants, nonionic surfactant, alkyl polyglycosides, wettingagents, surfactants, flocculants, and other chemicals that are known tothose of skill in the art. Examples of the use of such chemicaladditives in a drilling fluid recycling system are described in U.S.Pat. Nos. 6,977,048 and 6,881,349, previously incorporated by referencein their entirety.

In system 500, the mixture in second cuttings storage vessel 502 may befurther separated via chemical injection, as described above, throughagitation, or through time-based separation. However, when separationoccurs to a desirable level, the mixture may be removed from secondcuttings storage vessel 502 via line 518. In this embodiment, themixture in line 518 may include a substantially solids mixture that maybe in a positive condition, as described above, and as such, may bepumped into a filter press 506 a. Such a condition may exist in a systemwherein chemical flocculant is injected into second cuttings storagevessel 502, thereby creating flocs with a density greater than themixture. However, in other embodiments, the solution in cuttings storagevessel 502 is in a substantially positive condition, and solid sedimentdoes not form. In such a system the mixture may be pumped from cuttingsstorage vessel 502 into hydrocarbon filter 506 b, or may be pumped viaan outlet in the side of second cuttings storage vessel 502 through asecondary line 519 to hydrocarbon filter 506 b. As described above, byproviding a plurality of lines from second cuttings storage vessel 502,the rate of drilling fluid processing may be increased.

Additional components for facilitating the removal of solid and oilcomponents of the mixture may be added to system 500 without departingfrom the scope of the present disclosure. Examples of such componentsmay include hydrocyclones, centrifuges, and skimmers, which may be addedas additional inline components during the direction of the mixturebetween first cuttings storage vessel 501 and second cuttings storagevessel 502 and components of module 503. As such, those of ordinaryskill in the art will appreciate that additional separation componentsmay be added to module 503, or may operate independent of module 503,and still be considered a component of system 500.

In certain embodiments, a multiple step chemical additive systemincluding first dosing tank 513 a and second dosing tanks 513 b may beconfigured to provide for multiple step chemical injection. For example,first dosing tank 513 a may include separation chemicals, while seconddosing tank 513 b may include flocculation chemicals. As such, dosing ofa chemical to promote separation of solids and other particulate matterfrom the liquid phase may occur in first cuttings storage vessel 501,while a flocculant is added from second dosing tanks 513 b to secondcuttings storage vessel 502. Those of ordinary skill in the art willappreciate that the addition of the chemical additives, including bothseparation and flocculation chemicals, may be controlled according tosystem parameters. Exemplary system parameters include a rate ofseparation and flocculation within the cuttings storage vessels, a rateof flow through the system, a volume of fluid within the system, and aweight of fluid within the system. Additionally, the chemical additivesmay be dosed according to such flow rates and/or according to volumesand weights of either the chemical additives or the fluids within thesystem. Furthermore, in certain embodiments, more than one separationand/or flocculation chemical may be added to either first or secondcuttings storage vessel 501 and 502.

After the mixture is processed by filter system 506, the cleaneddrilling fluid is directed to cleaned fluid reservoir 508. The fluidsmay then be collected and/or used in other portions of the drillingoperation, as described above.

Referring to FIG. 6, a system 600 for recycling drilling fluid accordingto one embodiment of the present disclosure is shown. In thisembodiment, system 600 includes a first cuttings storage vessel 601, asecond cuttings storage vessel 602, and a module 603. Module 603includes a pump 604, a valve 605, a filter system 606, a power supply620, and a programmable logic controller (“PLC”) (621). Valve 605provides for the control of fluid communication between first cuttingsstorage vessel 601 and second cuttings vessel 602 and/or drilling wastereservoir 607. As described above, all structural elements includingdrilling waste reservoir 607 and supply lines may be existing structuresat a drilling location.

System 600 works similarly to systems 300, 400, and 500, describedabove.

Briefly, a drilling fluid enters first cuttings storage vessel 601through supply line 609. The fluid is allowed to separate, and is pumpedvia inline pump 604 to valve 605. If the mixture from first cuttingsstorage vessel 601 is in a positive condition, the mixture is sent todrilling waste reservoir 607, or otherwise directed to a press filter(not independently illustrated) of filter system 606. If the mixture isin a negative condition, the mixture is directed to second cuttingsstorage vessel 602 via line 612. After further separation in secondcuttings storage vessel 602, the fluid is transferred to filter system606 for the additional removal of residual solids and/or hydrocarbons.The cleaned fluid is then directed to a cleaned fluids reservoir 608 foruse in other drilling operations.

In this embodiment, system 600 includes an independent power source 620for providing power to components of module 603. Power source 620 iselectrically connected to, for example, pump 604, valve 605, filtersystem 606, and/or PLC 621. Those of ordinary skill in the art willappreciate that such a power source may provide primary or auxiliarypower for powering components of module 603. In other embodiments, powersource 620 may be merely an electrical conduit for connecting a powersource on a rig (not shown) via an electrical cable 622, to module 603.

System 600 also includes PLC 621, operatively connected to, for example,pump 604, valve 605, and/or filter system 606. In this embodiment, PLC621 provides instructions for controlling the rate of flow of themixture of first cuttings storage vessel 601 through valve 605 to, forexample, second cuttings storage vessel 602. Controlling the rate offlow may include controlling the operation of pump 604 or valve 605. Inone embodiment, PLC 621 may provide for the automated control of valve605, directing the flow of the mixture from first cuttings storagevessel 601 to second cuttings storage vessel 602. Such control may occuras a result of valve 605 including a sensor. Examples of such sensorsmay include density sensors, conductivity sensors, or other sensorsknown to those in the art for determining a condition of a drillingfluid, such as, a density. Such an embodiment may allow module 603 toautomatically control the speed of the recycling of the drilling fluidto obtain an optimal condition for a drilling operation. An optimalcondition may include cleaning a drilling fluid to a determined levelfor use in the drilling operation. Those of ordinary skill in the artwill appreciate that such a system may be used to reduce the hydrocarboncontent of a fluid to less than, for example, 20 ppm, to meetenvironmental regulations defining the condition for disposable fluids.In other operations, the hydrocarbon content may be reduced tosubstantially 35 ppm, and the fluid may be used in other components ofthe drilling operation. Those of ordinary skill in the art willappreciate that such hydrocarbon levels are merely examples of how sucha system 600 may be used to clean and recycle drilling fluids.

Still referring to FIG. 6, PLC 621 may provide for externalcommunication of module 603 with a rig management system. Rig managementsystems may include, on-rig systems used to control drilling operations,drill cuttings cleaning operations, environmental systems, and datacollection systems. As such, PLC 621 may record and/or analyze data suchas time of drilling fluid recycling, the amount of drilling fluidrecycled, the amounts of chemicals used in the operation of system 600,power usage, and other data that may be used by a drilling operator tofurther increase the efficiency of the drilling operation. In stillother embodiments, PLC 621 may allow module 603 to be operativelycoupled with other modules to use the cleaned fluids of system 600 to,for example, clean tanks, reinject cuttings into a wellbore, createslurry, or further remediate drill cuttings and/or fluids.

To promote such interconnectivity, module 603 may include a datacommunication device, such as, for example, a wireless access point 623,thereby allowing module 603 and/or system 600 to communicate remotelywith other systems, modules, rig management systems, or other remotecommunication devices known to those of skill in the art. Such an accesspoint 623 may further allow module 603 to be controlled, or dataacquired therefrom remotely.

Those of ordinary skill in the art will appreciate that components ofsystems 300, 400, 500, and 600 may be interchanged, interconnected, andotherwise assembled in a drilling fluid recovery system. As such, toaddress the specific requirements of a drilling operation, thecomponents of the systems and modules disclosed herein may provide foran interchangeable and adaptable system for the cleaning and/orrecycling of drilling fluids at a drilling location.

Advantageously, embodiments disclosed herein may provide for systems andmethods that more efficiently clean and recycle drilling fluids on adrilling rig. Because offshore platform space is often limited, andcrane operations to transfer drilling fluid cleaning systems are oftenexpensive and dangerous, embodiments of the present disclosure maydecrease the cost of drilling operations by decreasing the number ofcrane lifts. Additionally, modules of the present disclosure may allowfor existing infrastructure of an offshore platform to perform multiplefunctions, such as, allowing cuttings storage vessels to be used in boththe storage and transfer of cuttings, as well as, being used in adrilling fluid recycling operation. Furthermore, the system may promotethe use of environmentally safe cleaning operations (i.e., recyclingdrilling fluid), thereby enhancing the environmental condition of thedrilling operation. Finally, by decreasing time associated with changingdrilling equipment for cleaning operations, the present disclosure maydecrease downtime of a drilling operation, thereby increasing drillingefficiency, while decreasing cost.

While the disclosure has been described with respect to a limited numberof embodiments, those skilled in the art, having benefit of thisdisclosure, will appreciate that other embodiments may be devised whichdo not depart from the scope of the disclosure as described herein.Accordingly, the scope of the disclosure should be limited only by theattached claims.

1. A system for recycling a drilling fluid comprising: a first cuttingsstorage vessel; a second cuttings storage vessel; and a module fluidlyconnected to the first and second cuttings storage vessels, the modulecomprising: a valve configured to fluidly connect the first and secondcuttings storage vessels; a filter system configured to fluidly connectto at least the second cuttings storage vessel; and at least one pump tofacilitate the flow of a fluid between the first and second cuttingsstorage vessels.
 2. The system of claim 1, wherein the valve isconfigured to automatically adjust the flow of the fluid between thefirst and second cuttings storage vessels.
 3. The system of claim 1,wherein the valve comprises a sensor.
 4. The system of claim 3, whereinthe sensor is one selected from a group consisting of a density sensorand a conductivity sensor.
 5. The system of claim 1, wherein the filtersystem comprises a hydrocarbon filter.
 6. The system of claim 1, whereinthe filter system comprises a filter press.
 7. The system of claim 1,further comprising a second pump to facilitate the flow of the fluidbetween the second cuttings storage vessel and a third storage vessel.8. The system of claim 7, wherein the second pump is configured tofacilitate the flow of the fluid through the filter system.
 9. Thesystem of claim 1, further comprising a programmable logic controlleroperatively coupled to the module.
 10. The system of claim 9, whereinthe programmable logic controller provides instructions to the valve forcontrolling the flow of fluid between the first and second cuttingsstorage vessels.
 11. The system of claim 1, further comprising achemical additive system comprising at least one chemical dosing tank.12. The system of claim 11, wherein the chemical dosing tank isconfigured to supply at least one of a separation chemical and aflocculant to one or more of the cuttings storage vessels.
 13. Thesystem of claim 11, wherein the chemical additive system comprises: afirst chemical dosing tank configured to provide a separation chemicalto the first cuttings storage vessel; and a second chemical dosing tankconfigured to provide a flocculant to the second cuttings storagevessel.
 14. A module for use at a drilling location comprising: a valvefor directing drilling fluid between at least a first cuttings storagevessel disposed outside the module and a second cuttings storage vesseldisposed outside the module; a filter system for filtering the drillingfluid; and at least one pump for facilitating the flow of the fluidbetween at least the first and second cuttings storage vessels.
 15. Themodule of claim 14, further comprising a programmable logic controlleroperatively coupled to the module.
 16. The module of claim 15, whereinthe programmable logic controller provides instructions to the valve forcontrolling the flow of fluid between the first and second cuttingsstorage vessels.
 17. The module of claim 14, wherein the valve isconfigured to automatically adjust the flow of the fluid between thefirst and second cuttings storage vessels.
 18. The module of claim 14,wherein the valve comprises a sensor.
 19. The module of claim 18,wherein the sensor is one selected from a group consisting of a densitysensor and a conductivity sensor.
 20. The module of claim 14, whereinthe filter system comprises at least a filter selected from a groupconsisting of hydrocarbon filters and press filters.
 21. The module ofclaim 14, further comprising: an emulsion clearance agent additiondevice; and a flocculant addition device.
 22. A method of operating adrilling fluid recycling system comprising: using a vessel for cuttingsstorage; and operating the vessel in a drilling fluid recycling system,the operating comprising: connecting a module to the vessel, the modulecomprising: a valve for directing drilling fluid between at least afirst cuttings storage vessel disposed outside the module and a secondcuttings storage vessel disposed outside the module; a filter system forfiltering the drilling fluid; and at least one pump for facilitating theflow of the fluid between at least the first and second cuttings storagevessels; and providing a flow of drilling fluid to the vessel.
 23. Themethod of claim 22, further comprising: using the vessel for cuttingstransport.
 24. The method of claim 22, further comprising: mixing anemulsion clearance agent with the drilling fluid in the vessel, whereinthe emulsion clearance agent is a mixture of a non-ionic surfactant andan anionic surfactant.
 25. The method of claim 22, wherein the vessel isadapted for pneumatic transfer of cuttings.